The Emergency Planning and Community Right-to-Know Act (EPCRA) established the requirements for Federal, state and local governments, Indian Tribes, and industry regarding reporting on hazardous and toxic chemicals. EPCRA was passed in response to concerns regarding environmental and safety hazards posed by the storage and handling of toxic chemicals. These concerns were triggered by the disaster in Bhopal, India caused by the accidental release of methyl isocyanate. Requirements for the preparation and submittal of Tier II Reports were established more than 20 years ago in response to these types of chemical release accidents. Despite the time since the passage of these regulations, we have seen that some facilities are not submitting the Tier II reports in accordance with the deadline, and in some cases are simply failing to submit the reports.
Facilities covered by EPCRA requirements must submit an Emergency and Hazardous Chemical Inventory Form to the Local Emergency Planning Committee (LEPC), the State Emergency Response Commission (SERC), and the local fire department annually. Facilities provide either a Tier I or Tier II Form although most states require the Tier II Form. Some states and counties have requirements in addition to the Federal Tier II requirements.
The EPCRA Tier II Form submittal is due on March 1, 2012. The Tier II Form is required for chemicals that are stored at your facility above specific weight thresholds that are not exempted under the EPCRA regulations. The weight threshold varies for extremely hazardous substances (EHS) and is set at 10,000 pounds for other chemicals stored at your facility.
Tier II Forms must report the required information for each hazardous chemical present at your facility in quantities equal to or greater than established threshold amounts (discussed below), unless the chemicals are excluded. Hazardous chemicals are any substance for which your facility must maintain a Material Safety Data Sheet (MSDS) under OSHA’s Hazard Communication Standard (described at 29 CFR 1910.1200).
Section 311(e) of EPCRA excludes a number of substances. The OSHA regulations at Section 1910.1200(b) also stipulates various exemptions from the requirement for maintaining an MSDS for certain chemicals or materials. Minimum thresholds have been established for Tier II reporting under EPCRA Section 312. These thresholds are as follows:
- For Extremely Hazardous Substances (EHSs) – the reporting threshold is 500 pounds or the Threshold Planning Quantity (TPQ), whichever is lower. The current list of EHS chemicals and their TPQs is maintained at 40 CFR Part 355.
- For gasoline (all grades combined) at a retail gas station, the threshold level is 75,000 gallons, if the tank(s) was stored entirely underground and was in compliance at all times during the preceding calendar year with all applicable Underground Storage Tank (UST) requirements.
- For diesel fuel (all grades combined) at a retail gas station, the threshold level is 100,000 gallons, if the tank(s) was stored entirely underground and the tank(s) was in compliance at all times during the preceding calendar year with all applicable UST requirements.
- For all other hazardous chemicals for which facilities are required to have or prepare an MSDS, the minimum reporting threshold is 10,000 pounds.
Your facility needs to report hazardous chemicals that were present at your facility at any time during the previous calendar year at levels that equal or exceed these thresholds. The report covers the 2011 calendar year, beginning January 1 and ending December 31. For each chemical that your facility has listed, identify all the physical and health hazard boxes that apply. These hazard categories are defined in 40 CFR 370.2. The two health hazard categories and three physical hazard categories are a consolidation of the hazard categories defined in the OSHA Hazard Communication Standard, 29 CFR 1910.1200.
For each chemical that is reported, the Tier II form asks for specific information such as the maximum amount stored onsite, average daily amount stored onsite, number of days present onsite, and storage codes and storage location information (for non-confidential chemicals). You may elect to withhold location information on a specific chemical from disclosure to the public. The Tier II instructions provide details for submittal of confidential information. The owner or operator or the officially designated representative of the owner or operator must certify that all information included in the Tier II submission is true, accurate, and complete. An original signature is required on the submission.
To obtain Tier II reporting procedures and requirements for your state, please click on the state where your facility is located on EPA’s Tier II Chemical Inventory Reports page.
The completed Tier II form(s) must be submitted to each of the following organizations: SERC, LEPC, and the fire department with jurisdiction over your facility. If you have any questions about EPCRA Tier II reporting requirements and whether your facility may be subject to these regulations, please contact Paul Tomiczek III, REM, P.E. at firstname.lastname@example.org or 800-365-2324. More information on EPCRA Tier II Reporting obligations and instructions for completing the Tier II report are provided at http://www.epa.gov/oem/docs/chem/t2-instr.pdf.
U.S. EPA continues to roll out new subparts and revisions to the Greenhouse Gas (GHG) Reporting Rule (40 CFR 98). This time we take a look at Subpart W – Petroleum and Natural Gas Systems which was published in the November 30, 2010 Federal Register. GHG emissions from this industry are generated by combustion (e.g., heaters, engines, furnaces, etc.), fugitive equipment leaks, and process vents.
As with the other 40 CFR 98 subparts, facilities that emit 25,000 metric tons (mt) or more of carbon dioxide equivalents (CO2e) per year must report. However, the definition of a facility is slightly more complicated here than for other subparts.
First, there are eight segments of the petroleum and natural gas industry that need to be considered. Each industry segment is defined in the rule (see §98.230) and more detailed descriptions can be found in the 144-page Background Technical Support Document. The eight industry segments are:
- Offshore petroleum and natural gas production;
- Onshore petroleum and natural gas production;
- Natural gas processing plants;
- Natural gas transmission compression;
- Underground natural gas storage;
- Liquefied natural gas (LNG) storage;
- LNG import and export equipment; and
- Natural gas distribution.
The next step in defining a facility under Subpart W is to consider the 21 categories of emission sources that have been identified within the eight industry segments. For example, the onshore petroleum and natural gas production facility (Segment 2) includes 19 different types of emission sources that need to be inventoried to determine if the annual 25,000 mt CO2e applicability threshold is exceeded (e.g., dehydrator vents, flare stacks, and well testing vents).
For six of the industry segments, the facility definition stops there. One simply accounts for all of the sources located on contiguous property or under common ownership/control and for which calculation approaches have been provided in the rule. Two of the industry segments require one more step to define the facility.
For the Onshore Petroleum and Natural Gas Production industry segment, the rule defines a facility as all of the equipment on or associated with a well pad that is under common control or ownership and that is located within a single hydrocarbon basin, as defined by the American Association of Petroleum Geologists Geologic Provinces Code Map. (This 1991 publication is not provided by EPA but can be obtained from AAPG here. As one might imagine, geologic provinces cover large areas (e.g., most of Pennsylvania as well as parts of New York, West Virginia, and five other southern states is covered by Code 160A – Appalachian Basin Eastern Overthrust Area). This means that operations at multiple well pad locations will have to be aggregated for applicability determinations and reporting purposes.
The facility definition for the Natural Gas Distribution industry segment is not based on geography. Instead, EPA has simply included “all distribution pipelines, metering stations, and regulating stations” that physically deliver natural gas to end users as operated by a single local distribution company (LDC). The caveat relative to an LDC is that it is regulated as a separate operating company by a public utility commission or it is operated as an independent municipally-owned distribution system.
The eight industry segments and the associated 21 categories of emission sources for which GHG calculation procedures have been developed are summarized in the following table.
Summary of Source Types by Industry Segment
|Source Type||Industry Segments
(see list above)
|Natural gas pneumatic device venting||X||X||X|
|Natural gas driven pneumatic pump venting||
|Acid gas removal vent||X||X|
|Well venting for liquids unloading||X|
|Gas well venting during well completions and workovers with hydraulic fracturing||X|
|Gas well venting during well completions and workovers without hydraulic fracturing||X|
|Blowdown vent stacks||X||X||X||X|
|Onshore production storage tanks||X|
|Transmission storage tanks||X|
|Well testing venting and flaring||X|
|Associated gas venting and flaring||X|
|Centrifugal compressor venting||X||X||X||X||X||X|
|Reciprocating compressor and packing venting||X||X||X||X||X||X|
|Other emissions from equipment leaks||X||X||X||X||X||X||X|
|Population count and emissions factor||X||X||X||X||X|
|Vented equipment leaks and flare emissions identified in BOEMRE GOADS study||X|
|Enhanced oil recovery hydrocarbon liquids dissolved CO2||X|
|Enhanced oil recovery injection pump blowdown||X|
|Onshore petroleum and natural gas production and natural gas distribution combustion emissions||X||
EPA has developed extensive checklists that describe in detail what needs to be monitored at the seven onshore industry segments. For example, Natural Gas Distribution facilities (Segment 8 ) need to account for the total number of leaking control valves and the operating time of leaking orifice meters, among many other things. Emission calculation methods specified in the rule include engineering estimates, direct measurement, leak detection emission factors, and equipment counts with population emission factors.
The rule requires affected facilities to develop Monitoring Plans in accordance with the General Provisions by April 1, 2011. Best available monitoring methods (BAMM) will be allowed for certain data gathering requirements for periods up through December 31, 2011. Requests to use BAMM for extended periods must be submitted to EPA in accordance with the timing requirements specified in the rule (either April 30 or September 30, 2011).
CEC recommends that facilities carefully review the regulation, the EPA guidance, the applicability tools, and the emission estimation tools available at EPA’s site on their Greenhouse Gas Reporting Program page. If you are unclear about how this rule affects your facility, please contact one of CEC’s GHG experts: Kris Macoskey, 800-365-2324, email@example.com; John Yates, 800-759-5614, firstname.lastname@example.org; and Chris Dawdy, 866-250-3670, email@example.com. You may also email CEC’s GHG team for additional information at GHGENVHelp@cecinc.com.